US20180187499A1 - Top set liner hanger and packer with hanger slips above the packer seal - Google Patents
Top set liner hanger and packer with hanger slips above the packer seal Download PDFInfo
- Publication number
- US20180187499A1 US20180187499A1 US15/908,164 US201815908164A US2018187499A1 US 20180187499 A1 US20180187499 A1 US 20180187499A1 US 201815908164 A US201815908164 A US 201815908164A US 2018187499 A1 US2018187499 A1 US 2018187499A1
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- US
- United States
- Prior art keywords
- mandrel
- downhole tool
- moveable component
- tool according
- locking ring
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
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- 230000015572 biosynthetic process Effects 0.000 description 4
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- 230000004913 activation Effects 0.000 description 3
- 238000005553 drilling Methods 0.000 description 2
- 238000000605 extraction Methods 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- -1 steam Substances 0.000 description 2
- 238000003860 storage Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 238000010793 Steam injection (oil industry) Methods 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 239000003995 emulsifying agent Substances 0.000 description 1
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- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000003607 modifier Substances 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000000700 radioactive tracer Substances 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000009919 sequestration Effects 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
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Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
- E21B23/01—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
- E21B23/06—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/128—Packers; Plugs with a member expanded radially by axial pressure
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/129—Packers; Plugs with mechanical slips for hooking into the casing
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
Definitions
- Resource exploration systems employ a system of tubulars that extend from a surface downhole into a formation.
- the tubulars often include components having adjustable portions such as hangers, packers, screens and the like that may be remotely activated. Often times, remote activation includes introducing tools from the surface into the system of tubulars.
- the adjustable portions such as slips, valves and the like may create localized diameter changes of the downhole tubular. That is, portions of the downhole tubular may include components or tubulars having increased wall thickness associated with the adjustable portions that create localized diameter changes of the downhole tubular system. Reducing an overall number of diameter changes in a system of tubulars can lead to an overall cost savings in well bore construction and operation.
- a downhole tool including a mandrel, at least one moveable component mounted to the mandrel, and a locking ring mounted to the mandrel.
- the locking ring includes a plurality of locking ring segments that enable relative movement between the mandrel and the at least one moveable component.
- a plurality of circumferential spaces is arranged between corresponding ones of the locking ring segments.
- At least one load bar is arranged in at least one of the plurality of circumferential spaces. The at least one load bar is mechanically connected to the at least one moveable component.
- FIG. 1 depicts a resource exploration system including a seal assembly, in accordance with an exemplary embodiment
- FIG. 2 depicts a plan view of the seal assembly, in accordance with an aspect of an exemplary embodiment
- FIG. 3 depicts the seal assembly of FIG. 2 without a slip seat
- FIG. 4 depicts a partial cross-sectional view of an uphole end of the seal assembly, in accordance with an aspect of an exemplary embodiment
- FIG. 5 depicts the seal assembly of FIG. 3 after setting a plurality of slip members
- FIG. 6 depicts the seal assembly of FIG. 5 following axial shifting of a decoupling sleeve arranged at the uphole end;
- FIG. 7 depicts a partial cut-away view of a load bar passing between lock ring segments, in accordance with an aspect of an exemplary embodiment
- FIG. 8 depicts slip members engaged with a downhole end of a load bar, in accordance with an aspect of an exemplary embodiment
- FIG. 9 depicts the slip member of FIG. 8 disengaging from the load bar during setting, in accordance with an aspect of an exemplary embodiment.
- Resource exploration system 2 should be understood to include well drilling operations, resource extraction and recovery, CO 2 sequestration, and the like.
- Resource exploration system 2 may include a surface system 4 operatively connected to a downhole system 6 .
- Surface system 4 may include pumps 8 that aid in completion and/or extraction processes as well as fluid storage 10 .
- Fluid storage 10 may contain a gravel pack fluid or slurry (not shown) that is introduced into downhole system 6 .
- Downhole system 6 may include a system of tubulars 20 that are extended into a wellbore 21 formed in formation 22 .
- System of tubulars 20 may be formed from a number of connected downhole tools or tubulars 24 and include a liner top extension 25 that extend downhole to a seal assembly 27 through a non-expandable hanger or mandrel 28 .
- Seal assembly 27 is selectively deployed downhole of mandrel 28 in order to isolate one portion of wellbore 21 from another portion of wellbore 21 .
- non-expandable mandrel is meant to describe a mandrel that does not deform radially to engage walls of wellbore 21 or a well casing if present.
- non-expandable mandrel 28 includes a body 34 having an outer surface 35 , an inner surface (not separately labeled), an uphole end 36 , and a downhole end 37 mechanically coupled to seal assembly 27 .
- a moveable component or decoupling sleeve 39 is mechanically coupled to uphole end 36 of mandrel 28 .
- Decoupling sleeve 39 includes an uphole end portion 42 that receives liner top extension 25 and a downhole end portion 43 .
- Decoupling sleeve 39 supports a first plurality of shear members 45 that are designed to shear upon being exposed to a first force. It is to be understood that the particular type of shear members employed may vary.
- Non-expandable mandrel 28 supports a plurality of slip members, one of which is indicated at 48 .
- Slip members 48 include surface features 52 and may be radially outwardly extended to affix non-expandable mandrel 28 at a desired position relative to wellbore 21 .
- Non-expandable mandrel 28 is also shown to include a slip seat 53 ( FIG. 2 ) that partially covers body 34 .
- Slip seat 53 includes a plurality of windows, one of which is indicated at 55 , which provide an opening through which each slip member 48 may extend.
- a cover ring 57 ( FIG. 2 ) may be provided to partially cover another portion of body 34 adjacent downhole end 37 .
- Cover ring 57 includes window portions 59 that are positioned to accommodate radial outward movement of slip members 48 . Once deployed, surface features 52 on slip members 48 bite into wall portions (not separately labeled) of wellbore 21 to affix non-expandable mandrel 28 .
- Non-expandable mandrel 28 also includes a lock assembly 64 defined by a lock ring 65 ( FIG. 3 ) having a plurality of ridges 67 ( FIG. 6 ) arranged near uphole end 36 , a locking member 68 downhole from lock ring 65 , a first load ring 70 arranged near uphole end 36 and a second load ring 72 arranged at downhole end 37 .
- a plurality of load bars, one of which is indicated at 78 extends between first load ring 70 and second load ring 72 .
- Load bar 78 includes a plurality of ridges, one of which is indicated at 79 , that may be selectively aligned with ridges 67 on lock ring 65 .
- a load bar link 80 is arranged at first load ring 70 and mechanically links each of the plurality of load bars 78 .
- load bars 78 transfer an axial load from decoupling sleeve 39 to seal assembly 27 .
- Body 34 of non-expandable mandrel 28 includes a second plurality of shear members 85 that are designed to shear upon being exposed to a second force, which is less than the first force. Shear members 85 prevent axial loading of the plurality of load bars 78 prior to setting slip members 48 .
- Seal assembly 27 includes another moveable component that may take the form of a seal body 92 including an uphole end section 93 coupled to downhole end 37 of non-expandable mandrel 28 and a downhole end section 95 that supports a seal member 96 .
- Downhole end section 95 extends to a mandrel 97 having a tapered end 98 .
- seal assembly 27 is shifted toward mandrel 97 causing a radial outward expansion of seal member 96 .
- Seal member 96 engages with side walls (not separately labeled) of wellbore 21 . Seal member 96 fluidically isolates one portion (downhole) of wellbore 21 from another portion (uphole) of wellbore 21 .
- Seal assembly 27 includes a third plurality of shear members 106 that are designed to shear upon being exposed to a third force, which may be substantially equal to the second force.
- Tapered end 98 of mandrel 97 is positioned at downhole end 37 .
- the particular design of mandrel 97 including tapered end 98 ensures that a wall thickness (not shown) of mandrel 97 below the seal element 94 is equivalent or greater than a cross-sectional dimension of an associated liner. Therefore, pressure containment ratings of this system preserve liner pressure ratings.
- Gap 116 Prior to setting, a gap 116 exists between decoupling sleeve 39 and first load ring 70 as shown in FIG. 3 . Gap 116 is sized to be greater than an expected travel of decoupling sleeve 39 when setting slip members 48 .
- a tool 118 as shown in FIG. 4 is run into a system of tubulars 20 as part of a drill string 119 that extends from surface system 4 to set slip members 48 .
- Tool 118 which may take the form of a pusher tool, applies an axial force to the liner top extension which moves axially into non-expandable mandrel 28 causing the second plurality of shear members 85 to shear.
- the tool may include a ball seat (not shown).
- An activation ball (also not shown) may be introduced into wellbore 21 and guided to the ball seat. Fluid may be introduced into wellbore 21 to a selected pressure. The applied force passes through decoupling sleeve 39 into non-expandable mandrel 28 causing the second plurality of shear members 85 to shear allowing slip seat 53 to deploy slip members 48 as shown in FIG. 5 . At this point, the activation ball may be extruded.
- Tool 118 includes a designed amount of axial stroke. The axial stroke achieved while setting slip member 48 after the second shear member 85 shears, is not sufficient to load any other shear members of seal assembly 27 , e.g. shear members 45 and 106 .
- set down weight of system of tubulars 20 causes first plurality of shear members 45 to shear allowing decoupling sleeve 39 to shift further closing gap 116 as shown in FIG. 6 .
- the set down weight passes into first load ring 70 , through load bars 78 to second load ring 72 and into seal body 92 causing the third plurality of shear members 106 to shear allowing seal member 96 to travel onto tapered end 98 and expand radially outwardly creating an annular seal against an internal surface of wellbore 21 .
- load bars 78 extend along non-expandable mandrel with little, if any, increase in outer diameter. More specifically, load bars 78 pass between one or more locking ring segments 130 that collectively form lock ring 65 . Adjacent locking ring segments 130 are separated by a plurality of circumferential spaces 131 each of which defines a channel 132 that forms a gap 136 sized to receive one of load bars 78 .
- each slip member 48 includes a pair of tab members such as seen at 142 and at 143 on an adjacent slip member 48 .
- tab members 142 and 143 Prior to deployment of slip members 48 , tab members 142 and 143 nest within tab receiving recesses 146 formed in each load bar 78 .
- Each load bar 78 also includes a reduced thickness portion 149 to accommodate shorter deployment of slip members 48 . In this manner, slip members 48 will lock load bars 78 into place during deployment of system of tubulars 20 and setting of non-expandable mandrel 28 .
- load bars 78 may move freely to transmit an axial force from decoupling sleeve 39 to seal assembly 27 to set seal member 96 .
- the teachings of the present disclosure may be used in a variety of well operations. These operations may involve using one or more treatment agents to treat a formation, the fluids resident in a formation, a wellbore, and/or equipment in the wellbore, such as production tubing.
- the treatment agents may be in the form of liquids, gases, solids, semi-solids, and mixtures thereof.
- Illustrative treatment agents include, but are not limited to, fracturing fluids, acids, steam, water, brine, anti-corrosion agents, cement, permeability modifiers, drilling muds, emulsifiers, demulsifiers, tracers, flow improvers etc.
- Illustrative well operations include, but are not limited to, hydraulic fracturing, stimulation, tracer injection, cleaning, acidizing, steam injection, water flooding, cementing, etc.
- a downhole tool including a mandrel, at least one moveable component mounted to the mandrel, a locking ring mounted to the mandrel, the locking ring including a plurality of locking ring segments that enable relative movement between the mandrel and the at least one moveable component, a plurality of circumferential spaces arranged between corresponding ones of the locking ring segments, and at least one load bar arranged in at least one of the plurality of circumferential spaces, the at least one load bar being mechanically connected to the at least one moveable component.
- the at least one moveable component comprises a first moveable component and a second moveable component, the load bar being operatively connected between the first and second moveable components.
- the at least one load bar comprises a plurality of load bars arranged in corresponding ones of the plurality of circumferential spaces, each of the plurality of load bars being operatively connected to the first and second moveable components.
- the downhole tool according to any prior embodiment, further comprising: a load bar link mechanically connecting each of the plurality of load bars.
- first moveable component is a decoupling sleeve and the second moveable component comprises a seal body.
- the downhole tool according to any prior embodiment, further including one or more slip members selectively radially outwardly moveable relative to the mandrel.
- each of the plurality of locking ring segments includes a first plurality of ridges and the at least one load includes a second plurality of ridges that may be selectively aligned with the first plurality of ridges.
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
- Shaping Of Tube Ends By Bending Or Straightening (AREA)
- Lining Or Joining Of Plastics Or The Like (AREA)
Abstract
Description
- This application is a continuation of an earlier filing date from U.S. application Ser. No. 15/259,246 filed Sep. 8, 2016, the entire disclosure of which is incorporated herein by reference.
- Resource exploration systems employ a system of tubulars that extend from a surface downhole into a formation. The tubulars often include components having adjustable portions such as hangers, packers, screens and the like that may be remotely activated. Often times, remote activation includes introducing tools from the surface into the system of tubulars. The adjustable portions, such as slips, valves and the like may create localized diameter changes of the downhole tubular. That is, portions of the downhole tubular may include components or tubulars having increased wall thickness associated with the adjustable portions that create localized diameter changes of the downhole tubular system. Reducing an overall number of diameter changes in a system of tubulars can lead to an overall cost savings in well bore construction and operation.
- Disclosed is a downhole tool including a mandrel, at least one moveable component mounted to the mandrel, and a locking ring mounted to the mandrel. The locking ring includes a plurality of locking ring segments that enable relative movement between the mandrel and the at least one moveable component. A plurality of circumferential spaces is arranged between corresponding ones of the locking ring segments. At least one load bar is arranged in at least one of the plurality of circumferential spaces. The at least one load bar is mechanically connected to the at least one moveable component.
- Referring now to the drawings wherein like elements are numbered alike in the several Figures:
-
FIG. 1 depicts a resource exploration system including a seal assembly, in accordance with an exemplary embodiment; -
FIG. 2 depicts a plan view of the seal assembly, in accordance with an aspect of an exemplary embodiment; -
FIG. 3 depicts the seal assembly ofFIG. 2 without a slip seat; -
FIG. 4 depicts a partial cross-sectional view of an uphole end of the seal assembly, in accordance with an aspect of an exemplary embodiment; -
FIG. 5 . depicts the seal assembly ofFIG. 3 after setting a plurality of slip members; -
FIG. 6 depicts the seal assembly ofFIG. 5 following axial shifting of a decoupling sleeve arranged at the uphole end; -
FIG. 7 depicts a partial cut-away view of a load bar passing between lock ring segments, in accordance with an aspect of an exemplary embodiment; -
FIG. 8 depicts slip members engaged with a downhole end of a load bar, in accordance with an aspect of an exemplary embodiment; and -
FIG. 9 depicts the slip member ofFIG. 8 disengaging from the load bar during setting, in accordance with an aspect of an exemplary embodiment. - A resource exploration system, in accordance with an exemplary embodiment, is indicated generally at 2, in
FIG. 1 .Resource exploration system 2 should be understood to include well drilling operations, resource extraction and recovery, CO2 sequestration, and the like.Resource exploration system 2 may include asurface system 4 operatively connected to adownhole system 6.Surface system 4 may includepumps 8 that aid in completion and/or extraction processes as well asfluid storage 10.Fluid storage 10 may contain a gravel pack fluid or slurry (not shown) that is introduced intodownhole system 6. -
Downhole system 6 may include a system oftubulars 20 that are extended into awellbore 21 formed in formation 22. System oftubulars 20 may be formed from a number of connected downhole tools ortubulars 24 and include aliner top extension 25 that extend downhole to aseal assembly 27 through a non-expandable hanger ormandrel 28.Seal assembly 27 is selectively deployed downhole ofmandrel 28 in order to isolate one portion ofwellbore 21 from another portion ofwellbore 21. It is to be understood that the term “non-expandable mandrel” is meant to describe a mandrel that does not deform radially to engage walls ofwellbore 21 or a well casing if present. - In accordance with an aspect of an exemplary embodiment illustrated in
FIGS. 2-3 , non-expandablemandrel 28 includes abody 34 having anouter surface 35, an inner surface (not separately labeled), anuphole end 36, and adownhole end 37 mechanically coupled toseal assembly 27. A moveable component ordecoupling sleeve 39 is mechanically coupled touphole end 36 ofmandrel 28.Decoupling sleeve 39 includes anuphole end portion 42 that receivesliner top extension 25 and adownhole end portion 43.Decoupling sleeve 39 supports a first plurality ofshear members 45 that are designed to shear upon being exposed to a first force. It is to be understood that the particular type of shear members employed may vary. -
Non-expandable mandrel 28 supports a plurality of slip members, one of which is indicated at 48.Slip members 48 includesurface features 52 and may be radially outwardly extended to affixnon-expandable mandrel 28 at a desired position relative towellbore 21.Non-expandable mandrel 28 is also shown to include a slip seat 53 (FIG. 2 ) that partially coversbody 34.Slip seat 53 includes a plurality of windows, one of which is indicated at 55, which provide an opening through which eachslip member 48 may extend. A cover ring 57 (FIG. 2 ) may be provided to partially cover another portion ofbody 34adjacent downhole end 37.Cover ring 57 includeswindow portions 59 that are positioned to accommodate radial outward movement ofslip members 48. Once deployed, surface features 52 onslip members 48 bite into wall portions (not separately labeled) ofwellbore 21 to affixnon-expandable mandrel 28. -
Non-expandable mandrel 28 also includes alock assembly 64 defined by a lock ring 65 (FIG. 3 ) having a plurality of ridges 67 (FIG. 6 ) arranged nearuphole end 36, alocking member 68 downhole fromlock ring 65, afirst load ring 70 arranged nearuphole end 36 and asecond load ring 72 arranged atdownhole end 37. A plurality of load bars, one of which is indicated at 78 extends betweenfirst load ring 70 andsecond load ring 72.Load bar 78 includes a plurality of ridges, one of which is indicated at 79, that may be selectively aligned withridges 67 onlock ring 65. Aload bar link 80 is arranged atfirst load ring 70 and mechanically links each of the plurality ofload bars 78. As will be detailed below,load bars 78 transfer an axial load from decouplingsleeve 39 toseal assembly 27.Body 34 ofnon-expandable mandrel 28 includes a second plurality ofshear members 85 that are designed to shear upon being exposed to a second force, which is less than the first force.Shear members 85 prevent axial loading of the plurality ofload bars 78 prior to settingslip members 48. -
Seal assembly 27 includes another moveable component that may take the form of aseal body 92 including anuphole end section 93 coupled todownhole end 37 ofnon-expandable mandrel 28 and adownhole end section 95 that supports aseal member 96.Downhole end section 95 extends to amandrel 97 having atapered end 98. As will be detailed below,seal assembly 27 is shifted towardmandrel 97 causing a radial outward expansion ofseal member 96.Seal member 96 engages with side walls (not separately labeled) ofwellbore 21.Seal member 96 fluidically isolates one portion (downhole) ofwellbore 21 from another portion (uphole) ofwellbore 21.Seal assembly 27 includes a third plurality ofshear members 106 that are designed to shear upon being exposed to a third force, which may be substantially equal to the second force. Taperedend 98 ofmandrel 97 is positioned at downhole end 37. The particular design ofmandrel 97 includingtapered end 98 ensures that a wall thickness (not shown) ofmandrel 97 below the seal element 94 is equivalent or greater than a cross-sectional dimension of an associated liner. Therefore, pressure containment ratings of this system preserve liner pressure ratings. - Prior to setting, a
gap 116 exists betweendecoupling sleeve 39 andfirst load ring 70 as shown inFIG. 3 .Gap 116 is sized to be greater than an expected travel ofdecoupling sleeve 39 when settingslip members 48. Atool 118, as shown inFIG. 4 is run into a system oftubulars 20 as part of adrill string 119 that extends fromsurface system 4 to setslip members 48.Tool 118, which may take the form of a pusher tool, applies an axial force to the liner top extension which moves axially intonon-expandable mandrel 28 causing the second plurality ofshear members 85 to shear. - For example, the tool may include a ball seat (not shown). An activation ball (also not shown) may be introduced into
wellbore 21 and guided to the ball seat. Fluid may be introduced intowellbore 21 to a selected pressure. The applied force passes throughdecoupling sleeve 39 intonon-expandable mandrel 28 causing the second plurality ofshear members 85 to shear allowingslip seat 53 to deployslip members 48 as shown inFIG. 5 . At this point, the activation ball may be extruded.Tool 118 includes a designed amount of axial stroke. The axial stroke achieved while settingslip member 48 after thesecond shear member 85 shears, is not sufficient to load any other shear members ofseal assembly 27,e.g. shear members - At this point the tool may be released and a downhole operation, such as cementing may take place. After cementing, set down weight of system of
tubulars 20 causes first plurality ofshear members 45 to shear allowingdecoupling sleeve 39 to shiftfurther closing gap 116 as shown inFIG. 6 . The set down weight passes intofirst load ring 70, through load bars 78 tosecond load ring 72 and intoseal body 92 causing the third plurality ofshear members 106 to shear allowingseal member 96 to travel onto taperedend 98 and expand radially outwardly creating an annular seal against an internal surface ofwellbore 21. - In accordance with an aspect of an exemplary embodiment illustrated in
FIG. 7 , load bars 78 extend along non-expandable mandrel with little, if any, increase in outer diameter. More specifically, load bars 78 pass between one or morelocking ring segments 130 that collectively formlock ring 65. Adjacentlocking ring segments 130 are separated by a plurality of circumferential spaces 131 each of which defines achannel 132 that forms agap 136 sized to receive one of load bars 78. - In accordance with another aspect of an exemplary embodiment illustrated in
FIGS. 8 and 9 , eachslip member 48 includes a pair of tab members such as seen at 142 and at 143 on anadjacent slip member 48. Prior to deployment ofslip members 48,tab members tab receiving recesses 146 formed in eachload bar 78. Eachload bar 78 also includes a reducedthickness portion 149 to accommodate shorter deployment ofslip members 48. In this manner,slip members 48 will lock load bars 78 into place during deployment of system oftubulars 20 and setting ofnon-expandable mandrel 28. Onceslip member 48 are set, load bars 78 may move freely to transmit an axial force fromdecoupling sleeve 39 to sealassembly 27 to setseal member 96. - The teachings of the present disclosure may be used in a variety of well operations. These operations may involve using one or more treatment agents to treat a formation, the fluids resident in a formation, a wellbore, and/or equipment in the wellbore, such as production tubing. The treatment agents may be in the form of liquids, gases, solids, semi-solids, and mixtures thereof. Illustrative treatment agents include, but are not limited to, fracturing fluids, acids, steam, water, brine, anti-corrosion agents, cement, permeability modifiers, drilling muds, emulsifiers, demulsifiers, tracers, flow improvers etc. Illustrative well operations include, but are not limited to, hydraulic fracturing, stimulation, tracer injection, cleaning, acidizing, steam injection, water flooding, cementing, etc.
- A downhole tool including a mandrel, at least one moveable component mounted to the mandrel, a locking ring mounted to the mandrel, the locking ring including a plurality of locking ring segments that enable relative movement between the mandrel and the at least one moveable component, a plurality of circumferential spaces arranged between corresponding ones of the locking ring segments, and at least one load bar arranged in at least one of the plurality of circumferential spaces, the at least one load bar being mechanically connected to the at least one moveable component.
- The downhole tool according to any prior embodiment, wherein the lock bar does not project radially proudly of the locking ring.
- The downhole tool according to any prior embodiment, wherein the at least one moveable component comprises a first moveable component and a second moveable component, the load bar being operatively connected between the first and second moveable components.
- The downhole tool according to any prior embodiment, wherein the at least one load bar comprises a plurality of load bars arranged in corresponding ones of the plurality of circumferential spaces, each of the plurality of load bars being operatively connected to the first and second moveable components.
- The downhole tool according to any prior embodiment, wherein the first moveable component is axially spaced from the second moveable component along the mandrel.
- The downhole tool according to any prior embodiment, further comprising: a load bar link mechanically connecting each of the plurality of load bars.
- The downhole tool according to any prior embodiment, wherein the first moveable component is a decoupling sleeve and the second moveable component comprises a seal body.
- The downhole tool according to any prior embodiment, further including one or more slip members selectively radially outwardly moveable relative to the mandrel.
- The downhole tool according to any prior embodiment, wherein the at least one moveable component is operatively connected to the one or more slip members.
- The downhole tool according to any prior embodiment, wherein each of the plurality of locking ring segments includes a first plurality of ridges and the at least one load includes a second plurality of ridges that may be selectively aligned with the first plurality of ridges.
- The downhole tool according to any prior embodiment, wherein the at least one load bar is axially shiftable relative to the plurality of locking ring segments.
- The terms “about” and “substantially” are intended to include the degree of error associated with measurement of the particular quantity based upon the equipment available at the time of filing the application. For example, “about” can include a range of ±8% or 5%, or 2% of a given value.
- While one or more embodiments have been shown and described, modifications and substitutions may be made thereto without departing from the spirit and scope of the invention. Accordingly, it is to be understood that the present invention has been described by way of illustrations and not limitation.
Claims (11)
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
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US15/908,164 US10570686B2 (en) | 2016-09-08 | 2018-02-28 | Top set liner hanger and packer with hanger slips above the packer seal |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US15/259,246 US10233709B2 (en) | 2016-09-08 | 2016-09-08 | Top set liner hanger and packer with hanger slips above the packer seal |
US15/908,164 US10570686B2 (en) | 2016-09-08 | 2018-02-28 | Top set liner hanger and packer with hanger slips above the packer seal |
Related Parent Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US15/259,246 Continuation US10233709B2 (en) | 2016-09-08 | 2016-09-08 | Top set liner hanger and packer with hanger slips above the packer seal |
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US20180187499A1 true US20180187499A1 (en) | 2018-07-05 |
US10570686B2 US10570686B2 (en) | 2020-02-25 |
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US15/259,246 Active 2037-04-20 US10233709B2 (en) | 2016-09-08 | 2016-09-08 | Top set liner hanger and packer with hanger slips above the packer seal |
US15/908,164 Active US10570686B2 (en) | 2016-09-08 | 2018-02-28 | Top set liner hanger and packer with hanger slips above the packer seal |
Family Applications Before (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US15/259,246 Active 2037-04-20 US10233709B2 (en) | 2016-09-08 | 2016-09-08 | Top set liner hanger and packer with hanger slips above the packer seal |
Country Status (7)
Country | Link |
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US (2) | US10233709B2 (en) |
AU (1) | AU2017325575B2 (en) |
BR (1) | BR112019003840A2 (en) |
GB (1) | GB2569490B (en) |
MX (1) | MX2019002745A (en) |
NO (1) | NO20190437A1 (en) |
WO (1) | WO2018048526A1 (en) |
Families Citing this family (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10233709B2 (en) * | 2016-09-08 | 2019-03-19 | Baker Hughes, A Ge Company, Llc | Top set liner hanger and packer with hanger slips above the packer seal |
US10760363B2 (en) | 2018-02-19 | 2020-09-01 | Baker Hughes, A Ge Company, Llc | Lock ring segments biased into locked position while retained in position with an exterior profile |
Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3195646A (en) * | 1963-06-03 | 1965-07-20 | Brown Oil Tools | Multiple cone liner hanger |
US20090038808A1 (en) * | 2007-08-08 | 2009-02-12 | Baker Hughes Incorporated | Tangentially-loaded high-load retrievable slip system |
US10233709B2 (en) * | 2016-09-08 | 2019-03-19 | Baker Hughes, A Ge Company, Llc | Top set liner hanger and packer with hanger slips above the packer seal |
Family Cites Families (14)
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US4307781A (en) * | 1980-01-04 | 1981-12-29 | Baker International Corporation | Constantly energized no-load tension packer |
US4662453A (en) | 1986-01-29 | 1987-05-05 | Halliburton Company | Liner screen tieback packer apparatus and method |
US4753444A (en) | 1986-10-30 | 1988-06-28 | Otis Engineering Corporation | Seal and seal assembly for well tools |
US6431277B1 (en) | 1999-09-30 | 2002-08-13 | Baker Hughes Incorporated | Liner hanger |
US6467540B1 (en) * | 2000-06-21 | 2002-10-22 | Baker Hughes Incorporated | Combined sealing and gripping unit for retrievable packers |
US20020070503A1 (en) | 2000-12-08 | 2002-06-13 | Zimmerman Patrick J. | High temperature and pressure element system |
US7383891B2 (en) * | 2004-08-24 | 2008-06-10 | Baker Hughes Incorporated | Hydraulic set permanent packer with isolation of hydraulic actuator and built in redundancy |
US7546872B2 (en) | 2006-12-08 | 2009-06-16 | Baker Hughes Incorporated | Liner hanger |
WO2009146411A1 (en) | 2008-05-29 | 2009-12-03 | Schlumberger Canada Limited | Wellbore packer |
NO2898175T3 (en) | 2012-10-01 | 2018-04-14 | ||
CA2815848A1 (en) * | 2013-02-25 | 2014-08-25 | Resource Well Completion Technologies Inc. | Wellbore packer and method |
US10208552B2 (en) | 2013-08-02 | 2019-02-19 | Halliburton Energy Services, Inc. | Well packer with shock dissipation for setting mechanism |
GB2535053B (en) * | 2014-01-23 | 2021-01-20 | Halliburton Energy Services Inc | Testable isolation packer |
US10364640B2 (en) * | 2016-09-26 | 2019-07-30 | Weatherford Technology Holdings, Llc | Packer setting during high flow rate |
-
2016
- 2016-09-08 US US15/259,246 patent/US10233709B2/en active Active
-
2017
- 2017-08-03 WO PCT/US2017/045271 patent/WO2018048526A1/en active Application Filing
- 2017-08-03 AU AU2017325575A patent/AU2017325575B2/en not_active Ceased
- 2017-08-03 GB GB1904802.4A patent/GB2569490B/en not_active Expired - Fee Related
- 2017-08-03 MX MX2019002745A patent/MX2019002745A/en unknown
- 2017-08-03 BR BR112019003840A patent/BR112019003840A2/en not_active Application Discontinuation
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2018
- 2018-02-28 US US15/908,164 patent/US10570686B2/en active Active
-
2019
- 2019-04-01 NO NO20190437A patent/NO20190437A1/en not_active Application Discontinuation
Patent Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3195646A (en) * | 1963-06-03 | 1965-07-20 | Brown Oil Tools | Multiple cone liner hanger |
US20090038808A1 (en) * | 2007-08-08 | 2009-02-12 | Baker Hughes Incorporated | Tangentially-loaded high-load retrievable slip system |
US10233709B2 (en) * | 2016-09-08 | 2019-03-19 | Baker Hughes, A Ge Company, Llc | Top set liner hanger and packer with hanger slips above the packer seal |
Also Published As
Publication number | Publication date |
---|---|
US20180066486A1 (en) | 2018-03-08 |
US10233709B2 (en) | 2019-03-19 |
NO20190437A1 (en) | 2019-04-01 |
GB2569490B (en) | 2021-12-01 |
GB201904802D0 (en) | 2019-05-22 |
GB2569490A (en) | 2019-06-19 |
AU2017325575A1 (en) | 2019-04-11 |
BR112019003840A2 (en) | 2019-06-18 |
AU2017325575B2 (en) | 2020-03-05 |
WO2018048526A1 (en) | 2018-03-15 |
US10570686B2 (en) | 2020-02-25 |
MX2019002745A (en) | 2019-05-09 |
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